Remote set tool with contingency trigger and system

ABSTRACT

A remote set tool arrangement including a tool, a primary trigger operatively connected to the tool, and a contingency trigger operatively connected to the tool. A borehole system including a borehole in a subsurface formation, a string in the borehole, and the remote setting tool arrangement disposed within or as a part of the string.

CROSS REFERENCE TO RELATED APPLICATIONS

This application claims the benefit of an earlier filing date from U.S.Provisional Application Ser. No. 63/246,533 filed Sep. 21, 2021, theentire disclosure of which is incorporated herein by reference.

BACKGROUND

In the resource recovery and fluid sequestration industries, it is oftennecessary to set tools in a downhole environment. Hydrostatically settools are common, using such things as burst disks to determine thelocation for setting based upon hydrostatic pressure reaching athreshold level that is related to depth. Remote setting of tools isdesirable and the art is always receptive to improvements in this area.

SUMMARY

An embodiment of a remote set tool arrangement including a tool, aprimary trigger operatively connected to the tool, and a contingencytrigger operatively connected to the tool.

An embodiment of a borehole system including a borehole in a subsurfaceformation, a string in the borehole, and the remote setting toolarrangement disposed within or as a part of the string.

BRIEF DESCRIPTION OF THE DRAWINGS

The following descriptions should not be considered limiting in any way.With reference to the accompanying drawings, like elements are numberedalike:

FIG. 1 is a side view of a tool with primary trigger;

FIG. 2 is a cross sectional view illustrating the trigger portion ofFIG. 1 and a contingency trigger in a closed position;

FIG. 3 is the view of FIG. 2 illustrating the contingency trigger in anopen position;

FIG. 4 is an enlarged view of FIG. 3 ;

FIG. 5 is a cross sectional view illustrating the trigger portion ofFIG. 1 and an alternate contingency trigger in a closed position;

FIG. 6 is an enlarged view of a break-off plug;

FIG. 7 is the view of FIG. 5 illustrating the contingency trigger in anintermediate position;

FIG. 8 is the view of FIG. 5 illustrating the contingency trigger in anopen position;

FIG. 9 is a cross sectional view illustrating the trigger portion ofFIG. 1 and an alternate contingency trigger arrangement in a closedposition;

FIG. 10 is a cross sectional view of a prior art punch tool that isemployable to open the contingency trigger illustrated in FIG. 9 ;

FIG. 11 is a view of a prior art cutting tool that is employable to openthe contingency trigger illustrated in FIG. 9 ;

FIG. 12 is a cross sectional view illustrating the trigger portion ofFIG. 1 and an alternate contingency trigger arrangement in a closedposition;

FIG. 13 is a view related to FIG. 1 that shows a fluid path from thetrigger to the pressure chamber of a tool;

FIG. 14 is a cross section view showing passthroughs that are used forthe fluid path illustrated in FIG. 13 ;

FIGS. 15 and 16 are slightly rotated cross sectional views of the toolof FIG. 1 where the fluid path can be additionally understood; and

FIG. 17 is a view of a borehole system including the remote set toolwith contingency trigger disclosed herein.

DETAILED DESCRIPTION

A detailed description of one or more embodiments of the disclosedapparatus and method are presented herein by way of exemplification andnot limitation with reference to the Figures.

Referring to FIG. 1 , a remote set tool arrangement 10 is illustrated.The arrangement 10 includes a tool 12 to be set, a primary trigger 14 toset the tool, and a contingency trigger 16 visible in FIGS. 2-9 . Thetool 12 may be a packer or any other settable tool and particularly asettable tool that responds to hydraulic pressure. In embodiments, thehydraulic pressure may be hydrostatic pressure. The primary trigger 14is a remotely actuatable trigger that upon signal opens a port. In anembodiment, trigger 14 is an e-trigger such as that commerciallyavailable from Wellbor Technology, Houston Tex. Trigger 14 may respondto an electric signal, an acoustic signal, an identification chip (RF,Nuclear, etc.), a gravity or fluid conveyed object, pressure cycles,etc. The contingency trigger 16 comprises a separate fluid pathway thatis controlled and is openable upon command if the primary trigger doesnot function as designed.

Referring to FIGS. 2-4 , a first embodiment of contingent trigger 16 ais illustrated. Contingent trigger 16 a is disposed within the samehousing 18 as is trigger 14 but need not be in that location solely. Itis contemplated that the contingent trigger 16 a may be anywhere betweenthe primary trigger and the tool to be set. The trigger 16 a providesaccess to pressure (hydrostatic or hydraulic) from another fluid pathway20. Fluid pathway 20 is connectable to an inside diameter (ID) 22 of thearrangement 10, which is distinct from the primary fluid pathway 24 inthis embodiment that extends into fluid contact with an annulus 26 aboutthe arrangement 10. The fluid pathway 20 is segregated from the ID 22 bya sliding sleeve 28 that is sealed within the arrangement 10 by seals 30such as o-rings. The sleeve 28 includes a port 32 that can be alignedwith the fluid pathway 20 upon movement of the sleeve 28. The sleeve 28may be moved by conveying an object onto a seat therein, by a shiftingtool, etc. Once the port 32 is aligned with the pathway 20. fluidpressure from the ID is connected to a primary actuation pathway 34 thatleads to the tool 12. FIG. 2 depicts a closed position of the slidingsleeve 28 and FIG. 3 depicts an open position of the sliding sleeve 28.FIG. 4 , is simply an enlarged view of FIG. 2 for clarity.

Referring to FIGS. 5-8 , another embodiment of the contingency trigger16 b is illustrated. Contingency trigger 16 b comprises a break-off plug38 that defines an opening 40 therein. When a tip 42 is broken off theplug 38, fluid may flow through the opening 40. The plug 38 is disposedin a fluid pathway 44 that is otherwise similar to pathway 20. Alsosimilar to the foregoing embodiment is a sliding plug breaker 46 similarto sleeve 28 but which requires no seals and whose port 48 also acts asa cleaver to shear off the tip 42. It can be appreciated by comparingFIGS. 5 and 6 that the tip 42 is in a different portion of the port 48but not yet severed and then compare to FIG. 8 where the port 48 hasmoved beyond the plug 38 and has severed the tip 42. The port 48 is influid communication with the opening 40 because of a manifold area 50that bridges features 40 and 48 when the sliding member 46 is in theposition where the tip 42 has already been sheared. The sliding member46 can be moved in the same ways contemplated above for sleeve 28.

in yet another embodiment of the contingency trigger 16 c, referring toFIG. 9 , a pathway 52, similar to pathway 20 is closed off by a thinwall 54 or a disk (would look the same so not numbered or separatelyshown). In this embodiment, no seals are needed because there is nopressure path without the thin wall or disk being disrupted. Theembodiment is sometimes provided with a location profile 56 to ensure atool to open the thin wall/disk 54 will be properly registered. Toolsthat may be used to open the thin wall/disk include those illustrated inFIGS. 10 and 11 both of which represent prior art devices that may berun to depth to open the thin wall/disk 54. Respectively, these are apunch tool and a rotary pipe cutter tool. Both tools are availablecommercially from Baker Hughes and need not be explained in detail.

In yet another embodiment of the contingency trigger 16 d, referring toFIG. 12 , an incremental movement mechanism 56 is employed. A detailedexplanation of such a mechanism is not needed since the mechanism itselfis commercially available from Baker Hughes, Houston Tex. and iscolloquially known as a Cyclic Trigger. Its employment as a part of thecontingency 16 d in combination with other elements of the invention isnew. The mechanism 56 is ported to the inside diameter 22 of thearrangement 10 by pathway 57. Pressure cycles in the ID 22 willincrement the mechanism 56 until a secondary pathway 58 fluidly linksthe annulus 26 around arrangement 10 to a connector pathway 59 thatconnects to the primly actuation pathway 34.

In an embodiment of the arrangement described herein, triggering occursfrom a position downhole of the tool to be set. In order to enhance andsimplify sealing requirements, a full-length feedthrough 60 is used anda partial length feedthrough 62 is used for the setting operation of thearrangement 10. FIGS. 13-16 are useful in understanding the particularconstruction. While a control line extends all the way through thefeedthrough 60, the partial length feedthrough 62 is fluid containingwithout a control line extending all the way therethrough but ratheronly a couple of inches into the partial feedthrough 62. Sealing of thecontrol lines is accomplished at nuts 64, 66, and 70. Nut 64 is at thetrigger, nut 66 is at an uphole end of the feedthrough 60 adjacent nut70, which seals the control line to partial feedthrough 62. The partialfeedthrough 62 then conveys fluid to the pressure chamber 68, which maybe an atmospheric pressure chamber in some embodiments, of tool 12.

Referring to FIG. 17 , a borehole system 80 is illustrated. The system80 includes a borehole 82 in a subsurface formation 84. A string 86 isdisposed in the borehole 82. A remote set tool arrangement 10 isdisposed within or as a part of the string 86.

Set forth below are some embodiments of the foregoing disclosure:

Embodiment 1: A remote set tool arrangement including a tool, a primarytrigger operatively connected to the tool, and a contingency triggeroperatively connected to the tool.

Embodiment 2: The arrangement as in any prior embodiment wherein theprimary trigger is an e-trigger.

Embodiment 3: The arrangement as in any prior embodiment wherein thecontingency trigger comprises a redundant flow path and a valve.

Embodiment 4: The arrangement as in any prior embodiment wherein theredundant flow path accesses an actuation flow path between andincluding a housing of the primary trigger and the tool.

Embodiment 5: The arrangement as in any prior embodiment wherein thevalve is a sliding sleeve.

Embodiment 6: The arrangement as in any prior embodiment wherein thecontingency trigger comprises a break-off plug.

Embodiment 7: The arrangement as in any prior embodiment wherein thecontingency trigger further comprises a sliding plug breaker.

Embodiment 8: The arrangement as in any prior embodiment wherein thecontingency trigger comprises a redundant flow path and a rupturableclosure.

Embodiment 9: The arrangement as in any prior embodiment wherein theclosure is a thin wall portion covering the redundant flow path.

Embodiment 10: The arrangement as in any prior embodiment wherein theclosure is a burst disk.

Embodiment 11: The arrangement as in any prior embodiment wherein thecontingency trigger comprises a cyclic trigger.

Embodiment 12: The arrangement as in any prior embodiment wherein thetool includes a plurality of control line feedthroughs.

Embodiment 13: The arrangement as in any prior embodiment wherein theplurality of control line feedthroughs include one that begins at an endof the tool and terminates at an actuation pressure chamber of the tool.

Embodiment 14: The arrangement as in any prior embodiment wherein theend is an uphole end.

Embodiment 15: The arrangement as in any prior embodiment wherein anactuation pathway begins downhole of the tool, extends through a firstof the plurality of control lines, reverses direction and extendsthrough the one of the plurality of control lines.

Embodiment 16: The arrangement as in any prior embodiment wherein acontrol line of the plurality of control lines extending through the onefeedthrough is sealingly terminated at the actuation pressure chamber.

Embodiment 17: A borehole system including a borehole in a subsurfaceformation, a string in the borehole, and the remote setting toolarrangement as in any prior embodiment disposed within or as a part ofthe string.

The use of the terms “a” and “an” and “the” and similar referents in thecontext of describing the invention (especially in the context of thefollowing claims) are to be construed to cover both the singular and theplural, unless otherwise indicated herein or clearly contradicted bycontext. Further, it should be noted that the terms “first,” “second,”and the like herein do not denote any order, quantity, or importance,but rather are used to distinguish one element from another. The terms“about”, “substantially” and “generally” are intended to include thedegree of error associated with measurement of the particular quantitybased upon the equipment available at the time of filing theapplication. For example, “about” and/or “substantially” and/or“generally” can include a range of ±8% or 5%, or 2% of a given value.

The teachings of the present disclosure may be used in a variety of welloperations. These operations may involve using one or more treatmentagents to treat a formation, the fluids resident in a formation, aborehole, and/or equipment in the borehole, such as production tubing.The treatment agents may be in the form of liquids, gases, solids,semi-solids, and mixtures thereof. Illustrative treatment agentsinclude, but are not limited to, fracturing fluids, acids, steam, water,brine, anti-corrosion agents, cement, permeability modifiers, drillingmuds, emulsifiers, demulsifiers, tracers, flow improvers etc.Illustrative well operations include, but are not limited to, hydraulicfracturing, stimulation, tracer injection, cleaning, acidizing, steaminjection, water flooding, cementing, etc.

While the invention has been described with reference to an exemplaryembodiment or embodiments, it will be understood by those skilled in theart that various changes may be made and equivalents may be substitutedfor elements thereof without departing from the scope of the invention.In addition, many modifications may be made to adapt a particularsituation or material to the teachings of the invention withoutdeparting from the essential scope thereof. Therefore, it is intendedthat the invention not be limited to the particular embodiment disclosedas the best mode contemplated for carrying out this invention, but thatthe invention will include all embodiments falling within the scope ofthe claims. Also, in the drawings and the description, there have beendisclosed exemplary embodiments of the invention and, although specificterms may have been employed, they are unless otherwise stated used in ageneric and descriptive sense only and not for purposes of limitation,the scope of the invention therefore not being so limited.

1. A remote set tool arrangement comprising: a tool having anatmospheric chamber; a primary trigger operatively connected to the tooland configured to communicate a pressure source to the atmosphericchamber upon triggering; and a contingency trigger operatively connectedto the tool and configured to communicate the pressure source to theatmospheric chamber upon triggering.
 2. The arrangement as claimed inclaim 1 wherein the primary trigger is an e-trigger.
 3. The arrangementas claimed in claim 1 wherein the contingency trigger comprises aredundant flow path and a valve.
 4. The arrangement as claimed in claim3 wherein the redundant flow path accesses an actuation flow pathbetween and including a housing of the primary trigger and the tool. 5.The arrangement as claimed in claim 3 wherein the valve is a slidingsleeve.
 6. The arrangement as claimed in claim 1 wherein the contingencytrigger comprises a break-off plug.
 7. The arrangement as claimed inclaim 6 wherein the contingency trigger further comprises a sliding plugbreaker.
 8. The arrangement as claimed in claim 1 wherein thecontingency trigger comprises a redundant flow path and a rupturableclosure.
 9. The arrangement as claimed in claim 8 wherein the closure isa thin wall portion covering the redundant flow path.
 10. Thearrangement as claimed in claim 8 wherein the closure is a burst disk.11. The arrangement as claimed in claim 1 wherein the contingencytrigger comprises a cyclic trigger.
 12. The arrangement as claimed inclaim 1 wherein the tool includes a plurality of control linefeedthroughs.
 13. The arrangement as claimed in claim 12 wherein theplurality of control line feedthroughs include one that begins at an endof the tool and terminates at an actuation pressure chamber of the tool.14. The arrangement as claimed in claim 13 wherein the end is an upholeend.
 15. The arrangement as claimed in claim 14 wherein an actuationpathway begins downhole of the tool, extends through a first of theplurality of control lines, reverses direction and extends through theone of the plurality of control lines.
 16. The arrangement as claimed inclaim 13 wherein a control line of the plurality of control linesextending through the one feedthrough is sealingly terminated at theactuation pressure chamber.
 17. A borehole system comprising: a boreholein a subsurface formation; a string in the borehole; and the remotesetting tool arrangement as claimed in claim 1 disposed within or as apart of the string.